EP2248867B1 - Zusatzmittel zur Erhöhung der Dichte einer Flüssigkeit für die Druckkontrolle eines Ringraumes - Google Patents

Zusatzmittel zur Erhöhung der Dichte einer Flüssigkeit für die Druckkontrolle eines Ringraumes Download PDF

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Publication number
EP2248867B1
EP2248867B1 EP10171324A EP10171324A EP2248867B1 EP 2248867 B1 EP2248867 B1 EP 2248867B1 EP 10171324 A EP10171324 A EP 10171324A EP 10171324 A EP10171324 A EP 10171324A EP 2248867 B1 EP2248867 B1 EP 2248867B1
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Prior art keywords
fluid
barite
solid
casing annulus
colloidal
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French (fr)
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EP2248867A1 (de
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Andrew J. Bradbury
Christopher A. Sawdon
Sonny Clary
William M. Reid
Tom Heinz
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MI LLC
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MI LLC
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    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B20/00—Use of materials as fillers for mortars, concrete or artificial stone according to more than one of groups C04B14/00 - C04B18/00 and characterised by shape or grain distribution; Treatment of materials according to more than one of the groups C04B14/00 - C04B18/00 specially adapted to enhance their filling properties in mortars, concrete or artificial stone; Expanding or defibrillating materials
    • C04B20/10—Coating or impregnating
    • C04B20/1018—Coating or impregnating with organic materials
    • C04B20/1029—Macromolecular compounds
    • C04B20/1033—Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B02—CRUSHING, PULVERISING, OR DISINTEGRATING; PREPARATORY TREATMENT OF GRAIN FOR MILLING
    • B02C—CRUSHING, PULVERISING, OR DISINTEGRATING IN GENERAL; MILLING GRAIN
    • B02C23/00—Auxiliary methods or auxiliary devices or accessories specially adapted for crushing or disintegrating not provided for in preceding groups or not specially adapted to apparatus covered by a single preceding group
    • B02C23/06—Selection or use of additives to aid disintegrating
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C09K8/032—Inorganic additives
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C09K8/035—Organic additives
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C09K8/34—Organic liquids
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/40—Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • C09K8/48—Density increasing or weighting additives
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/501—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls using spacer compositions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/502—Oil-based compositions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E21B21/062—Arrangements for treating drilling fluids outside the borehole by mixing components
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/18—Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts

Definitions

  • Sustained casing annulus pressure can be defined as any recorded pressure on casing strings, other than drive or structural strings, that cannot be bled to zero.
  • causes of sustained casing annulus pressure include leaks in tubing, casing, packers, wellhead packoffs, and poor or failed primary cement jobs.
  • Sustained casing annulus pressure can also be a significant safety issue for oil and gas producing wells.
  • approximately 150 Alaskan North Slope wells subject to casing annulus pressure buildup were shut-down by the operator out of safety concerns. This shut-down of considerable production capacity (reportedly about. 6 percent of total crude output) was a safety precaution taken in response to the rupture and fire at a well caused by casing annulus pressure buildup.
  • sustained casing annulus pressure is inserting a flexible hose into the restricted annuli of outer casing strings so high density fluids can be effectively displaced.
  • these high density fluids include high density brines specially formulated for injection and displacement of the existing fluids in the casing annulus. This displacement of the existing annulus fluid with a heavier (i.e. higher density) brine provides a simple way for an operator to regain control over sustained casing annulus pressures.
  • WO-A-98/03609 relates to an additive which increases the density of wellbore fluids used during the construction or repair of oil, gas, injection, water or geothermal wells.
  • the additive is comprised of solid colloidal particles of weight average particle diameter (D50) of less than 2 microns, the particles being deflocculated by the action of a dispersant, preferably incorporated during the process of grinding or comminution of the particles to the specified particle size.
  • the additives may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluids as well as in a dense media separating fluid or in a ship's ballast fluid.
  • US-A-4166582 describes a method of comminuting a solid material comprising calcium carbonate to obtain a product containing at least 60% by weight of particles smaller than 2 microns equivalent spherical diameter.
  • the method comprises forming an aqueous suspension of the solid material which has a solids content in the range of from 5% to 50% by weight of dry solids and contains a dispersing agent, comminuting the solid material in the suspension by agitating the suspension in admixture with a particulate grinding medium, separating from the suspension thereby obtained an aqueous suspension containing comminuted solid material at least 60% by weight of which is smaller than 2 microns equivalent spherical diameter, flocculating the comminuted solid material by means of an electrolyte having a multivalent cation, and dewatering the aqueous suspension containing the comminuted and flocculated solid material.
  • the present invention is defined by the appended claims.
  • the present invention is generally directed to the use of fluids for controlling casing annulus pressure, as well as methods for using such fluids.
  • the fluids used in the present invention include a polymer coated colloidal solid material that has been coated with a polymer added during the cominution (i.e. grinding) process for preparing the polymer coated colloidal solid material, a defined in claim 1.
  • One illustrative embodiment of the present invention includes a method of controlling the pressure of a casing annulus in a subterranean well.
  • the method includes, injecting into the casing annulus a composition including an oleaginous base fluid, and a polymer coated colloidal solid material.
  • the polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d 50 ) of less than two microns, and a polymeric dispersing agent absorbed to the surface of the solid particle.
  • the polymeric dispersing agent is absorbed to the surface of the solid particle during the cominution (i.e. grinding) process utilized to make the polymer coated colloidal solid material.
  • the base fluid utilized in the above illustrative embodiment can be an aqueous fluid or an oleaginous fluid and preferably is selected from: diesel oil, mineral oil, white oil, n-alkanes, and synthetic oils, and combinations and mixtures of these.
  • Suitable and illustrative colloidal solids are selected such that the solid particles are composed of a material of specific gravity of at least 2.68 and preferably are selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate, combinations and mixtures of these and other suitable materials that should be well known to one of skill in the art.
  • the polymer coated colloidal solid material has a weight average particle diameter (d 50 ) less than 2.0 microns.
  • d 50 weight average particle diameter
  • Another preferred and illustrative embodiment is such that at least 50% of the solid particles have a diameter less than 2 microns and more preferably at least 80% of the solid particles have a diameter less than 2 microns.
  • the particle diameter distribution in one illustratvie embodiment is such that greater than 25% of the solid particles have a diameter of less than 2 microns and more preferably greater than 50% of the solid particle have a diameter of less than 2 microns.
  • the polymeric dispersing agent utilized in one illustrative and preferred embodiment is selected from oleic acid, polybasic fatty acids, alkylbenzene sulphonic acids, alkane sulphonic acids, linear alpha olefin sulphonic acid, and alkaline earth metal salts of the foregoing acids; phospholipids; and synthetic polymers.
  • the present invention is directed to the use of a composition for controlling casing annulus pressure that includes a base fluid and a polymer coated colloidal solid material.
  • the polymer coated colloidal solid material is formulated so as to include a solid particle having an weight average particle diameter (d 50 ) of less than two microns; and a polymeric dispersing agent adsorbed to the surface of the colloidal solid particle.
  • the polymer coated colloidal solid material utilized and described herein is made by a method which includes grinding the solid particulate material and a polymeric dispersing agent for a sufficient time to achieve an weight average particle diameter (d 50 ) of less than two microns; and so that the polymeric dispersing agent is adsorbed to the surface of the solid particle.
  • d 50 weight average particle diameter
  • the illustrative grinding process is carried out in the presence of the base fluid which is an oleaginous fluid.
  • One of the most important functions of a fluid of the present invention is to contribute to the stability of the well bore, and control the flow of gas, oil or water from the pores of the formation in order to prevent, for example, the flow or blow out of formation fluids or the collapse of pressured earth formations.
  • the column of fluid in the hole exerts a hydrostatic pressure proportional to the depth of the hole and the density of the fluid.
  • High pressure formations may require a fluid with a specific gravity of up to 3.0.
  • a variety of materials are presently used to increase the density of fluids in the oil and gas well drilling and production industry. Such materials include dissolved salts such as sodium chloride, calcium chloride and calcium bromide. Alternatively powdered minerals such as barite, calcite and hematite are added to a fluid to form a suspension of increased density. It is also known to utilize finely divided metal such as iron as a weight material.
  • PCT Patent Application WO85/0511 discloses a drilling fluid where the weight material includes iron/steel ball-shaped particles having a diameter less than 250 microns and preferentially between 15 and 75 microns. It has also been proposed to use calcium or iron carbonate (see for example US-A-4,217,229 ).
  • One desirable characteristic of the fluids utilized in the context of the present invention is that the particles form a stable suspension, and do not readily settle out.
  • a second desirable characteristic is that the suspension should exhibit a low viscosity in order to facilitate pumping and to minimize the generation of high pressures.
  • Another desireable characteristic is that the fluid slurry should exhibit low filtration rates (fluid loss).
  • weighting agents such as powdered barium sulfate (“barite”) exhibit an average particle diameter (d 50 ) in the range of 10-30 microns.
  • d 50 average particle diameter
  • a gellant or viscosifier such as bentonite for water based fluids, or organically modified bentonite for oil based fluids.
  • Polymeric viscosifiers such as xanthan gum may be also added to slow the rate of the sedimentation of the weighting agent.
  • the fluid viscosity plastic viscosity
  • the sedimentation (or "sag") of particulate weighting agents is important for maintaining or controlling pressures in a wellbore, a wellbore annulus or casing annuli. Should there be a gradual separation of the solid and liquid phases of a fluid over a period of time, the density of the fluid in the wellbore, the annulus or casing annulus becomes inhomogeneous and the hydrostatic pressure exerted on the wellbore formations may be less than the pressure of wellbore formation fluids, resulting in well control issues and potentially a blow out.
  • the additives of this invention comprise dispersed solid colloidal particles with a weight average particle diameter (d 50 ) of less than 2 microns that are coated with a polymeric defloculating agent or dispersing agent.
  • the fine particle size will generate suspensions or slurries that will show a reduced tendency to sediment or sag, whilst the polymeric dispersing agent on the surface of the particle control the inter-particle interactions and thus will produce lower rheological profiles. It is the combination of fine particle size and control of colloidal interactions that reconciles the two objectives of lower viscosity and minimal sag.
  • the polymeric dispersant is coated onto the surface of the particulate weighting during the grinding process utilized to form the colloidal particle. It is believed that during the course of the grinding process, newly exposed particle surfaces become polymer coated thus resulting in the properties exhibited by the colloidal solids of the present invention.
  • Experimental data has shown that colloidal solid material created in the absence of the polymeric dispersant results in a concentrated slurry of small particles that is an unpumpable paste or gel.
  • a polymeric dispersant is added during the grinding process. It is believed that this difference provides an advantageous improvement in the state of dispersion of the particles compared to post addition of the polymeric dispersant to fine particles.
  • the polymeric dispersant is chosen so as it provides the suitable colloidal inter-particle interaction mechanism to make it tolerant to a range of common wellbore contaminants, including salt saturated.
  • a method of grinding a solid material to obtain the solid colloidal particle so of the present invention is well known for example from British Patent Specification No 1,472,701 or No 1,599,632 .
  • the mineral in an aqueous suspension is mixed with a polymeric dispersing agent and then ground within an agitated fluidized bed of a particulate grinding medium for a time sufficient to provide the required particle size distribution.
  • An important preferred embodiment aspect of the present invention is the presence of the dispersing agent in the step of "wet" grinding the mineral. This prevents new crystal surfaces formed during the grinding step from forming agglomerates which are not so readily broken down if they are subsequently treated with a dispersing agent.
  • the weighting agent of the present invention is formed of particles that are composed of a material of specific gravity of at least 2.68.
  • Materials of specific gravity greater than 2.68 from which colloidal solid particles that embody one aspect of the present invention include one or more materials selected from but not limited to barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite or other iron ores, olivine, siderite, strontium sulfate.
  • barium sulfate barite
  • calcium carbonate dolomite, ilmenite, hematite or other iron ores, olivine, siderite, strontium sulfate.
  • Normally the lowest wellbore fluid viscosity at any particular density is obtained by using the highest density colloidal particles.
  • other considerations may influence the choice of product such as cost, local availability and the power required for grinding.
  • the weight average particle diameter (d 50 ) of the colloidal solid particles is less than 2.0 microns.
  • Another preferred and illustrative embodiment is such that at least 50% of the solid particles have a diameter less than 2 microns and more preferably at least 80% of the solid particles have a diameter less than 2 microns.
  • the particle diameter distribution in one illustrative embodiment is such that greater than 25% of the solid particles have a diameter of less than 2 microns and more preferably greater than 50% of the solid particle have a diameter of less than 2 microns. This will enhance the suspension's characteristics in terms of sedimentation or sag stability without the viscosity of the fluid increasing so as to make it unpumpable.
  • the polymer coated colloidal particles used in the invention may be provided as a concentrated slurry in an oleaginous liquid.
  • the oleaginous liquid should have a kinematic viscosity of less than 10 centistokes (10 mm 2 /s) at 40 °C and, for safety reasons, a flash point of greater than 60 °C.
  • Suitable oleaginous liquids are for example diesel oil, mineral or white oils, n-alkanes or synthetic oils such as alpha-olefin oils, ester oils or poly(alpha-olefins).
  • the dispersing agent may be selected for example among carboxylic acids of molecular weight of at least 150 such as oleic acid and polybasic fatty acids, alkylbenzene sulphonic acids, alkane sulphonic acids, linear alpha-olefin sulphonic acid or the alkaline earth metal salts of any of the above acids, phospholipids such as lecithin, synthetic polymers such as Hypermer OM-1 (trademark of ICI).
  • carboxylic acids of molecular weight of at least 150 such as oleic acid and polybasic fatty acids, alkylbenzene sulphonic acids, alkane sulphonic acids, linear alpha-olefin sulphonic acid or the alkaline earth metal salts of any of the above acids, phospholipids such as lecithin, synthetic polymers such as Hypermer OM-1 (trademark of ICI).
  • This invention has a surprising application in controlling casing annulus pressure.
  • the new particulate weighting agents have the ability to stabilize the laminar flow regime, and delay the onset of turbulence. It is possible to formulate fluids for several applications that will be able to be pumped faster before turbulence is encountered, so giving essentially lower pressure drops at equivalent flow rates. This ability to stabilize the laminar flow regime although surprising is adequately demonstrated in heavy density muds of 20 pounds per gallon (2.39 g/cm 3 ) or higher. Such high density muds using conventional weighting agents, with a weight average particle diameter of 10 to 30 ⁇ m, would exhibit dilatancy with the concomitant increase in the pressure drops due to the turbulence generated. The ability of the weighting agent to stabilize the flow means that high density fluids with acceptable rheology are feasible with lower pressure drops.
  • ground barite a standard grade of API barite, having a weight average particle diameter (D 50 ) of about 20 microns ; a untreated barite (M) having an average size of 3 -5 microns made by milling/grinding barite while in the dry state and in the absence of a dispersant, with and colloidal barite according the present invention (with a D 50 from 0.5 microns to 2.0 microns), with a polymeric dispersant included during a "wet" grinding process.
  • D 50 weight average particle diameter
  • M untreated barite
  • M colloidal barite according the present invention
  • the colloidal barite of the present invention has a particle size distribution that is very different from that of API barite. Specifically one should be able to determine that greater than about 90% (by volume) of the colloidal barite of the present invention has a particle diameter less than about 5 microns. In contrast, less than 15 percent by volume of the particles in API specification barite have a particle diameter less than 5 microns.
  • the polymeric dispersant is IDSPERSETM XT an anionic acrylic ter-polymer of molecular weight in the range 40,000-120,000 with carboxylate and other functional groups commercially available from M-I LLC. Houston, Texas. This preferred polymer is advantageously stable at temperature up to 200 °C, tolerant to a broad range of contaminant, gives good filtration properties and do not readily desorb off the particle surface.
  • two 13.0 ppg (1.56 g/cm 3 ) fluid formulations are compared, one weighted with conventional API barite and the second weighted with polymer coated colloidal barite (PCC barite) made in accordance with the teachings of the present invention, as a 2.2sg liquid slurry.
  • PCC barite polymer coated colloidal barite
  • Other additives in the formulation are included to provide additional control of pH, fluid loss, rheology, inhibition to reactive shale and claystones. These additives are available from M-1 Drilling Fluids.
  • PRODUCT Fluid A Fluid B PCC barite lbs/bbl (kg/m 3 ) 320.0 (907.2) API barite lbs/bbl (kg/m 3 ) 238.1 (675.0) Freshwater lbs/bbl (kg/m 3 ) 175.0 (496.1) 264.2 (749.0) Soda Ash lbs/bbl (kg/m 3 ) 0.4 (1.1) 0.4 (1.1) CelpoI ESL lbs/bbl (kg/m 3 ) 3.5 (9.9) 4.2 (11.9) Flotrol lbs/bbl (kg/m 3 ) 3.5 (9.9) 0 (0) Defoam NS lbs/bbl (kg/m 3 ) 0.4 (1.1) 0 (0) KCl lbs/bbl (kg/m 3 ) 32.9 (93.3) 36.1 (102.3) Glydril; MC lbs/bbl (kg/m 3 ) 10.5 (29.8) 10.5 (29.8) Duotec
  • Fluid A formulated with the polymer coated colloidal barite, had no solids separation with a sag factor of zero with a rheological profile much lower than a fluid weighted with conventional API barite.
  • Fluid A was formulated with the polymer coated colloidal barite of described above.
  • Fluid B was formulated with conventional API barite.
  • Fluid C was formulated with a commercial grade of non coated colloidal barite, of median particle size of 1.6 microns available from Highwood Resources Ltd., Canada. Post grinding addition of the coating polymer of the invention are included in the formulation of Fluids B and C to maintain the fluid in a deflocculated condition.
  • Samples of fluid A, B and C were purposely contaminated with bentonite to simulate the inclusion of naturally drilled solids in the formulation.
  • the samples were heat aged dynamically at 150 °F (66°C) for 16 hrs. Exemplary and representative results after aging are shown below.
  • PRODUCT Fluid A Fluid B PCC barite (2.4sg) lbs/bbl (kg/m 3 ) 265 (751) API barite lbs/bbl (kg/m 3 ) 265 (751) Freshwater lbs/bbl (kg/m 3 ) 238 (675) 293 (831) Soda Ash lbs/bbl (kg/m 3 ) 0.5 (1.4) 0.5 (1.4) KOH lbs/bbl (kg/m 3 ) 0.5 (1.4) 0.5 (1.4) PolyPlus RD lbs/bbl (kg/m 3 ) 0.5 (1.4) 0.5 (1.4) PolyPac UL 2.0 (5.7) 2.0 (5.7) Duovis lbs/bbl (kg/m 3 ) 1.0 (2.8) 0.75 (2.1) KCl lbs/lbbl (kg/m 3 ) 8.0 (23) 8.0 (23)
  • VST Viscometer Sag Test
  • ECF-614 additive is an organophilic clay additive available from M-I Drilling Fluids.
  • the fluid was heat aged statically for 4 days at 350°F.
  • the following table provides exemplary results.
  • FANN 35 Reading 120°F (49°C) Fluid A Initial Aged 600 rpm 107 45 300 rpm 64 28 6 rpm 7 3 3 rpm 5 2 PV (cps) 43 17 (8) YP (lbs/100sq.ft) (Pa) 21 11 (5) 10 sec gel (lbs/100sq.ft) (Pa) 6 (3) 4 (2) 10 min gel (lbs/100sq.ft) (Pa) 10 (5) 11 (5) Sag Factor 0.503
  • This experiment illustrates the ability of the fluids formulated utilizing the polymer coated colloidal solid material described above to be pumped in a commercially available apparatus for injecting viscous brine fluids into a casing annulus as part of a casing annulus pressure control program.
  • the test apparatus was an unmodified CARS TM unit commercially available from ABB Vetco, having 500 feet (152 m) of hose on the reel, a small hose inner diameter of 0.2 inches (5.1 mm), a hose fitting diameter of 0.1 inches (2.5 mm), and a nylon ball of 0.25 inch (6.4 mm) diameter.
  • a fluid in accordance with the present invention was formulated having a density of 21.5 ppg (2.58 g/cm 3 ) and pumped through the test unit in accordance with all the proper procedures.
  • the following table summarizes exemplary data: Inlet Air Pressure (PSI) Low Outlet Pressure (PSI) High Outlet Pressure (PSI) Total Flow (L) Elapsed Time (min) Calc Flow (GPM) Comments 130 1000 1700 1.3 4 0.12 Nylon ball in nozzle 130 1500 2000 1.7 2 0.32 Nylon ball in nozzle 130 1000 3000 1.4 2 0.26 Nylon ball in nozzle 130 1100 2900 1.4 2 0.26 Nylon ball in nozzle 130 1100 2900 1.3 2 0.25 Nylon ball in nozzle w/VR Plug 130 700 2900 0.9 2 0.17 Nylon ball in nozzle w/VR Plug 130 1000 3000 1.3 2 0.25 VR Plug - No ball 130 800 2200 1 2 0.19 No Ball or VR Plug 110 1400 2400 8 1:32 1.97 Water, VR Plug, No Ball Metric conversion
  • a similar test was carried out using a larger hose having a 0.670 inch (17.0 mm) inner diameter, a hose fitting of 0.25 inches (6.4 mm) inner diameter; a nozzle of 0.67 VPN and spring #H300385-46.
  • a fluid was formulated having a density of 21.5 ppg (2.58 g/cm 3 ) and pumped through the test unit in accordance with all the proper procedures.
  • fluids including the polymer dispersant coated colloidal barite used in the present invention can be readily pumped and injected into the casing annulus using commercially available technologies. It should also be appreciated that in contrast that if one were to attempt a similar experiment with API barite or finely milled barite, the particle sizes and the viscosity of either fluids would substantially prevent obtaining the above results.
  • This experiment illustrates the compatibility of a 22.4-pp (2.68 g/cm 3 ) fluid formulated in accordance with the teachings of the present invention with a 17.6 ppg (2.11 g/cm 3 ) field lignosulfonate annulus fluid.
  • the compatibility test consisted of measuring the rheology of the colloidal barite test fluid sample at 100, 120 and 150°F (38, 49 and 66°C) and then measuring the rheology of a 17.6-ppg (3.11 g/cm 3 ) lignosulfonate filed mud at 100, 120 and 150°F (38, 49 and 66°C).
  • This experiment is indicative of the ability of the fluids used in the present invention to displace a 17.6 ppg (2.11 g/cm 3 ) field lignosulfonate annulus fluid.
  • This test consisted of placing 50 mls of the 17.6 ppg (2.11 g/cm 3 ) lignosulfonate field mud in a 100 ml graduated cylinder.
  • a 22.4 ppg (2.68 g/cm 3 ) colloidal barite fluid was loaded into a 60 ml syringe with a 6" long blunt nose needle.
  • the tip of the needle was placed inside the graduated cylinder to 5 ml below the 50 ml mark and the colloidal barite fluid was then injected into the field mud sample at a rate of about 50 ml/minute.
  • the sample was then allowed to stand at room temperature for about 5 minutes. After the time had expired a hollow glass barrel was carefully inserted into the sample and run to bottom.
  • the hollow glass barrel was then capped and pulled from the graduate cylinder in a manner to obtain a sample of the fluids in the graduated cylinder.
  • the bottom half of the hollow glass cylinder contains the colloidal barite fluid of the present invention. This can be determined visually by the color change from the colloidal barite fluid (light tan to white) to the field mud (very dark brown).
  • the formation of the colloidal solid material by a high energy wet process in which API Barite of median particle size of 25-30 micron is reduced to a median particle size of less than 2 microns, is more efficient when the milling is done at high density, normally greater than 2.1sg, preferably at 2.5sg.
  • the volume or mass fraction of barite is very high. For example, at a specific gravity of 2.5, a 100kgs of the final product contains about 78kgs is barite. However, the resulting slurry still remains fluid.
  • the presence of the surface active polymer during the course of the cominution process is an important factor in achieving the results of the present invention.
  • the surface active polymer is designed to adsorb onto surface sites of the barite particles.
  • the polymer In the grinder, where there is a very high mass fraction of barite, the polymer easily finds it way onto the newly formed particle surfaces. Once the polymer 'finds' the barite - and in the environment of the grinder it has every chance to do so - a combination of the extremely high energy environment in the wet grinding mill (which can reach 85 to 90 C inside the mill), effectively ensures that the polymer is 'wrapped' around the colloidal size barite. As a result of this process it is speculated that no polymer 'loops' or 'tails' are hanging off the barite to get attached, snagged, or tangled up with adjacent particles. Thus it is speculated that the high energy and shear of the grinding process ensures the polymer remains on the barite permanently and thus the polymer doesn't desorb, or become detached.
  • one illustrative embodiment of the present invention includes a method of controlling the pressure of a casing annulus in a subterranean well.
  • the method includes, injecting into the casing annulus a composition including a base fluid, and a polymer coated colloidal solid material.
  • the polymer coated colloidal solid.material includes: a solid particle having an weight average particle diameter (d 50 ) of less than two microns, and a polymeric dispersing agent adsorbed to the surface of the solid particle during the course of the cominution process.
  • the base fluid utilized in the above illustrative embodiment is an oleaginous fluid and preferably is selected from: diesel oil, mineral oil, white oil, n-alkanes, and synthetic oils and combinations and mixtures of these.
  • Suitable and illustrative colloidal solids are selected such that the solid particles are composed of a material of specific gravity of at least 2.68 and preferably are selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate, combinations and mixtures of these and other suitable materials that should be well known to one of skill in the art.
  • the polymer coated colloidal solid material has a weight average particle diameter (d 50 ) less than 2.0 microns.
  • Another illustrative embodiment contains at least 60% of the solid particles have a diameter less than 2 microns or alternatively more than 25% of the solid particles have a diameter less than 2 microns.
  • Another illustrative embodiment of the present invention includes a method of controlling the pressure of a casing annulus in a subterranean well, the method including inserting into the casing annulus a sufficient amount of a flexible tubing so as to reach a predetermined depth, and pumping into the flexible tubing a pressure control composition so as to inject an effective amount of the pressure control composition into the casing annulus so as to substantially displace any existing fluid in the casing annulus.
  • the pressure control composition includes: an oleaginous base fluid as described harein, and a polymer coated colloidal solid material, in which the polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d 50 ) of less than two microns, and a polymeric dispersing agent adsorbed to the surface of the solid particle.
  • d 50 weight average particle diameter
  • Another illustrative embodiment contains at least 60% of the solid particles have a diameter less than 2 microns or alternatively more than 25% of the solid particles have a diameter less than 2 microns.
  • a preferred and illustrative embodiment includes solid particles composed of a material having a specific gravity of at least 2.68 and more preferably the colloidal solid is selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate and combinations and mixtures of these and other similar solids that should be apparent to one of skill in the art.
  • the polymer coated colloidal solid material used in the invention is formulated so as to include a solid particle having an weight average particle diameter (d 50 ) of less than two microns; and a polymeric dispersing agent coated onto the surface of the solid particle.
  • a method of making the polymer coated colloidal solid material includes grinding a solid particulate material and a polymeric dispersing agent for a sufficient time to achieve an weight average particle diameter (dso) of less than two microns; and so that the polymeric dispersing agent is adsorbed to the surface of the solid particle.
  • the illustrative grinding process is carried out in the presence of an oleaginous base fluid.

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Claims (11)

  1. Verwendung einer Zusammensetzung für die Druckkontrolle eines Ringraums in einem unterirdischen Bohrloch, wobei die Zusammensetzung ein ölartiges Basisfluid und einen polymerbeschichteten kolloidalen Feststoff umfasst, wobei der polymerbeschichtete kolloidale Feststoff enthält: Festpartikel mit einem gewichtsgemittelten Korndurchmesser (d50) geringer als zwei Mikrometer und ein auf die Oberfläche des Festpartikels adsorbiertes polymerisches Dispergiermittel.
  2. Verwendung gemäß Anspruch 1, wobei das ölartige Basisfluid ausgewählt ist aus Dieselöl, mineralischem Öl, Weißöl, n-Alkanen und synthetischen Ölen.
  3. Verwendung gemäß Anspruch 1, wobei das polymerische Dispergierungsmittel ausgewählt ist aus Ölsäure, polybasischen Fettsäuren, Alkylbenzolsulfonsäuren, Alkansulfonsäuren, linearer alpha-Olefinsulfonsäure und Alkalierdmetallsalzen der vorgenannten Säuren; Phospholipiden; und synthetischen Polymeren.
  4. Verwendung gemäß Anspruch 1, wobei die Festpartikel zusammengesetzt sind aus einem Werkstoff mit einer spezifischen Dichte von mindestens 2,68.
  5. Verwendung gemäß Anspruch 4, wobei die Festpartikel zusammengesetzt sind aus einem Werkstoff, ausgewählt aus Bariumsulfat (Baryt), Calciumcarbonat, Dolomit, Ilmenit, Hämatit, Olivin, Siderit, Strontiumsulfat und Kombinationen davon.
  6. Verwendung gemäß Anspruch 5, wobei die Festpartikel zusammengesetzt sind aus Bariumsulfat (Baryt).
  7. Verwendung gemäß Anspruch 1, wobei der polymerbeschichtete kolloidale Feststoff hergestellt wird mit einem Verfahren, umfassend Zermahlen des festen partikelförmigen Werkstoffs und des polymerischen Dispergiermittels in einem Nassmahlverfahren während einer Zeit, ausreichend um einen gewichtsgemittelten Korndurchmesser (d50) von geringer als zwei Mikrometer zu erhalten, und so, dass das polymerische Dispergiermittel auf die Oberfläche des Festpartikels adsorbiert wird.
  8. Verwendung gemäß Anspruch 7, wobei das Zermahlen in der Anwesenheit eines ölartigen Fluids ausgeführt wird.
  9. Verwendung gemäß Anspruch 8, wobei das ölartige Basisfluid ausgewählt ist aus Dieselöl, mineralischem Öl, Weißöl, n-Alkanen und synthetischen Ölen.
  10. Verfahren zur Druckkontrolle eines Ringraums in einem unterirdischen Bohrloch, das Verfahren umfassend Injizieren in den Ringraum einer Zusammensetzung aus irgendeinem der vorherigen Ansprüche.
  11. Verfahren gemäß Anspruch 10, wobei das Verfahren des Injizierens der Zusammensetzung in den Ringraum umfasst Einführen in den Ringraum einer ausreichenden Menge biegsamer Röhren, so dass eine vorbestimmte Tiefe erreicht wird, und Pumpen der Zusammensetzung in die biegsamen Röhren, so dass eine wirksame Menge der Zusammensetzung in den Ringraum injiziert wird, so dass etwaiges im Ringraum bestehendes Fluid verdrängt wird.
EP10171324A 2002-10-18 2003-10-14 Zusatzmittel zur Erhöhung der Dichte einer Flüssigkeit für die Druckkontrolle eines Ringraumes Expired - Lifetime EP2248867B1 (de)

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US10/274,528 US20030203822A1 (en) 1996-07-24 2002-10-18 Additive for increasing the density of a fluid for casing annulus pressure control
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DK1558695T3 (da) 2011-01-03
BR0315420A (pt) 2005-08-23
US20030203822A1 (en) 2003-10-30
MXPA05004122A (es) 2005-08-03
NZ539959A (en) 2007-03-30
NO20052368D0 (no) 2005-05-13
AU2003279939A1 (en) 2004-05-13
US7589049B2 (en) 2009-09-15
CA2502673A1 (en) 2004-05-06
NO20052368L (no) 2005-07-06
US20060188651A1 (en) 2006-08-24
OA13046A (en) 2006-11-10
EP2248867A1 (de) 2010-11-10
ATE549091T1 (de) 2012-03-15
EP1558695A1 (de) 2005-08-03
NO341021B1 (no) 2017-08-07
MX352810B (es) 2017-12-08
DE60334138D1 (de) 2010-10-21
DK2248867T3 (da) 2012-04-10
ATE480603T1 (de) 2010-09-15
WO2004037947A1 (en) 2004-05-06
EP1558695B1 (de) 2010-09-08
CA2502673C (en) 2011-06-28

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